## OP_YEAR STATE FACILITY_NAME ORISPL_CODE UNITID UNIT_TYPE_INFO

2000 ND Leland Olds 2817 1 Dry bottom wall-fired boiler
2001 ND Leland Olds 2817 1 Dry bottom wall-fired boiler
2002 ND Leland Olds 2817 1 Dry bottom wall-fired boiler
2003 ND Leland Olds 2817 1 Dry bottom wall-fired boiler
2004 ND Leland Olds 2817 1 Dry bottom wall-fired boiler
2005 ND Leland Olds 2817 1 Dry bottom wall-fired boiler
2006 ND Leland Olds 2817 1 Dry bottom wall-fired boiler
2007 ND Leland Olds 2817 1 Dry bottom wall-fired boiler
2008 ND Leland Olds 2817 1 Dry bottom wall-fired boiler
2009 ND Leland Olds 2817 1 Dry bottom wall-fired boiler
2010 ND Leland Olds 2817 1 Dry bottom wall-fired boiler 2011 ND Leland Olds 2817 1 Dry bottom wall-fired boiler



## 2000 ND Leland Olds 2817 2 Cyclone boiler
2001 ND Leland Olds 2817 2 Cyclone boiler
2002 ND Leland Olds 2817 2 Cyclone boiler
2003 ND Leland Olds 2817 2 Cyclone boiler
2004 ND Leland Olds 2817 2 Cyclone boiler
2005 ND Leland Olds 2817 2 Cyclone boiler
2006 ND Leland Olds 2817 2 Cyclone boiler
2007 ND Leland Olds 2817 2 Cyclone boiler
2008 ND Leland Olds 2817 2 Cyclone boiler
2009 ND Leland Olds 2817 2 Cyclone boiler
2010 ND Leland Olds 2817 2 Cyclone boiler 2011 ND Leland Olds 2817 2 Cy clone boiler

## PRIMARY_FUEL_INFO

SO2_CONTROL_INFO NOX_CONTROL_INFO Coal Low NOx Burner Technology (Dry Bottom only) Overfire Air Coal Low NOx Burner Technology (Dry Bottom only) Overfire Air Coal Low NOx Burner Technology (Dry Bottom only) Overfire Air Coal Low NOx Burner Technology (Dry Bottom only) Overfire Air Coal Low NOx Burner Technology (Dry Bottom only) Overfire Air Coal Low NOx Burner Technology (Dry Bottom only) Overfire Air Coal Low NOx Burner Technology (Dry Bottom only) Overfire Air Coal Low NOx Burner Technology (Dry Bottom only) Overfire Air Coal Low NOx Burner Technology (Dry Bottom only) Overfire Air Coal Low NOx Burner Technology (Dry Bottom only) Overfire Air Coal Low NOx Burner Technology (Dry Bottom only) Overfire Air Coal Low NOx Burner Technology (Dry Bottom only ) Overfire Air



## Coal Coal Coal Coal Coal Coal Coal Coal Coal Coal Overfire Air (Began Nov 01, 2009) Coal Overfire Air Coal Overfire Air

## PART_CONTROL_INFO

Electrostatic Precipitator Electrostatic Precipitator Electrostatic Precipitator Electrostatic Precipitator Electrostatic Precipitator Electrostatic Precipitator Electrostatic Precipitator Electrostatic Precipitator Electrostatic Precipitator Electrostatic Precipitator Electrostatic Precipitator Electrostatic Precipitator



## Electrostatic Precipitator Electrostatic Precipitator Electrostatic Precipitator Electrostatic Precipitator Electrostatic Precipitator Electrostatic Precipitator Electrostatic Precipitator Electrostatic Precipitator Electrostatic Precipitator Electrostatic Precipitator Electrostatic Precipitator Electrostatic Precipitator**CAMD Emissions Data**

STATE FACILITY NAME ORISPL CODE UNIT ID OP YEAR SUM OP TIME NUM

MONTHS REPORTED SO2

MASS SO2

RATE NOX

RATE NOX MASS CO2 MASS HEAT INPUT HEAT INPUT ND Leland Olds 2817 Unit 1 2000 8,251 12 16,863 1.811 0.250 2,344 2,027,259 18,620,905 2,257 ND Leland Olds 2817 1 2001 7,100 12 15,237 1.940 0.262 2,062 1,709,710 15,704,164 2,212 ND Leland Olds 2817 1 2002 8,525 12 16,655 1.731 0.268 2,581 2,094,645 19,239,865 2,257 ND Leland Olds 2817 1 2003 8,636 12 19,125 1.816 0.290 3,051 2,292,600 21,058,116 2,439 ND Leland Olds 2817 1 2004 7,209 12 15,448 1.801 0.290 2,510 1,867,410 17,152,685 2,379 ND Leland Olds 2817 1 2005 8,574 12 17,488 1.801 0.310 3,017 2,114,422 19,421,524 2,265 ND Leland Olds 2817 1 2006 8,600 12 17,768 1.886 0.314 2,965 2,051,707 18,845,504 2,191 ND Leland Olds 2817 1 2007 6,788 12 14,562 2.086 0.312 2,177 1,520,252 13,963,931 2,057 ND Leland Olds 2817 1 2008 8,603 12 17,926 2.021 0.320 2,855 1,931,403 17,740,432 2,062 ND Leland Olds 2817 1 2009 8,471 12 17,371 2.023 0.300 2,584 1,869,945 17,175,940 2,028 ND Leland Olds 2817 1 2010 7,733 12 17,203 2.249 0.288 2,188 1,665,414 15,297,310 1,978

ND Leland Olds 2817 Unit 2 2000 6,894 12 28,587 1.848 0.603 9,472 3,369,076 30,945,842 4,489 ND Leland Olds 2817 2 2001 8,225 12 36,219 1.907 0.664 12,718 4,134,522 37,976,687 4,618 ND Leland Olds 2817 2 2002 8,050 12 30,744 1.728 0.622 11,184 3,874,640 35,589,576 4,421 ND Leland Olds 2817 2 2003 6,632 12 25,598 1.793 0.609 8,813 3,108,955 28,556,587 4,306 ND Leland Olds 2817 2 2004 8,552 12 32,990 1.851 0.584 10,379 3,881,215 35,649,975 4,168 ND Leland Olds 2817 2 2005 8,532 12 30,887 1.727 0.572 10,241 3,894,585 35,772,845 4,193 ND Leland Olds 2817 2 2006 6,305 12 22,259 1.758 0.505 6,463 2,756,498 25,319,177 4,016 ND Leland Olds 2817 2 2007 8,352 12 33,450 1.977 0.501 8,452 3,684,722 33,845,154 4,052 ND Leland Olds 2817 2 2008 7,760 12 30,022 1.940 0.528 8,210 3,369,894 30,953,377 3,989 ND Leland Olds 2817 2 2009 7,120 12 26,782 1.922 0.474 6,635 3,033,690 27,865,279 3,914 ND Leland Olds 2817 2 2010 7,996 12 28,776 2.139 0.314 4,237 2,928,952 26,903,299 3,364 Averages 7,674 31,761,618 4,139

### 0.3

0.4 0.5 0.6 0.7**N O** **x E** **m i** **s s** **i o** **n s** **( l** **b /** **m m** **B t** **u )**  

# Leland **Olds NOx Emission Rates**

Unit 2

Unit 1

0 0.1 0.2

2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010**N O** **x E** **m i** **s s** **i o** **n s** **( l** **b /** **m m** **B t** **u )** 



### Year

### 6000

8000 10000 12000 14000**N O** **x E** **m i** **s s** **i o** **n s** **( t** **p y** **)** 

# Leland **Olds NOx Mass Emissions**

Unit 1

Unit 2

0 2000 4000

2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010**N O** **x E** **m i** **s s** **i o** **n s** **( t** **p y** **)**



### Year**Basin Electric Power--Leland Olds #2**  **SNCR from OA QPS Control Cost Manual, Section 4.2** 

**Given/A ssumptions**  Rating (MW ) 440 ND DOH report Fuel High Heating Value (Btu/lb) 6,548 Company report (8/06 Table 1.2-2) Maximum Fuel Consumption Rate (lb/hr) 7.8E+05 calculated from 5,130 ND DOH report (SIP Appendix B.1) (and the Fox report) Average Annual Fuel Consumption (lb) 5.94E+09 calculated 38,872,062 mmBtu/y r calculated from Fox report Number of SNCR Operating Days 365 calculated from 8,760 hr/yr Total system capacity factor 86.5% Fox report Uncontrolled NOx Concentration (lb/mmBtu) 0.67 ND DOH report (SIP Appendix B.1) (and the Fox report) NOx concentration after combustion controls 0.482 ND DOH report (SIP Appendix B.1) Required Controlled NOx Concentration (lb/mmBtu) 0.305 ND DOH report (SIP Appendix B.1) Source/State Total Capital Investmant estimate 7,800,000 $ calculated from Table 2.5-2 in the 5/27/09 company report ash product (Btu/mmBtu) 7.7E+04 OAQPS Control Cost Manual Stored Urea Concentration 50% OAQPS Control Cost Manual Injected Urea Concentration 10% OAQPS Control Cost Manual Reagent Heat of vaporization Hv (lb/Btu) 900 OAQPS Control Cost Manual Reagent Molecular Weight (g/mole) 60.06 OAQPS Control Cost Manual SR T 2 OAQPS Control Cost Manual Reagent Density (lb/ft3 @ 60F) 71.0 OAQPS Control Cost Manual Reagent Specific Volume (gal/ft3) 7.481 OAQPS Control Cost Manual NOx Molecular W eight (g/mole) 46.01 OAQPS Control Cost Manual Number of Days of Storage for Urea 14 OAQPS Control Cost Manual Equipment Life (years) 20 OAQPS Control Cost Manual Annual Interest Rate 7% OAQPS Control Cost Manual Inflation Since 1998 1.34 CEPCI 2009/CEPCI 1998 Water Consumption Cost ($/gal) 0.0004 OAQPS Control Cost Manual Electrical Power Cost ($/kWh) 0.038 $ calculated from 38.00 $ /MW hr from previous company report 50% Urea Solution Cost ($/gal) 2.25 $ calculated from 475 $ /ton 50% aqueous solution from Fox report Coal Cost ($/mmBtu) 0.91 $ Company report Ash Disposal Cost ($/ton) 11.28 $ OAQPS Control Cost Manual

### Boiler Calculations

1.3 Q B 

### = HVm -dot fuel 

### QB = 6548 Btu/lb * 783,445 lb/hr QB = 5130 mmB tu/hr

1.7 CF Plant 

### = actual m fuel 

### /maximum m fuel 

### CFPlant = 5.94E+09 lb/y r / 8760 hr/y r / 783,445 lb/hr CFPlant = 86.5%

1.8 CF SNCR 

### = t SNCR 

### /365 day s CFSNCR = 365 day s/ 365 day s CFSNCR = 100%

1.6 CF Total 

### = CF Plant 

### x CF SNCR 

### CFTotal = 87% * 100% CFTotal = 86.5%

1.9 η NOx 

### = (NOx in 

### – NOx out 

### ) / NOx in 

### ηNOx = ( 0.482 lb/m mB tu - 0.305 lb/m mB tu)/ 0.482 lb/m mB tu ηNOx = 37%

**Uncontrolled NOx emissions (tpy) 13,022** 

### Reagent Calculations 1.14 NSR = [2NOx in 

### – 0.7] η NOx 

### / NOx in 

### NSR = ( 2 * 0.482 + 0.7 ) * 37% / 0.482 NSR = 1.27

1.13 Utilization = η NOx



### /NSR Utilization = 29%

1.15 m-dot reagent 

### = NOx in 

### Q B 

### η NOx 

### NSR M reagent 

### /M NOx 

### /SR T 

### m-dotreagent = 0.482 * 5130 * 37% * 127% * 60.06 / 2 / 46.01 m-dotreagent = 751 lb/hr

1.16 m-dot sol 

### = m -dot reagent 

### /C sol 

### m-dotsol = 751 / 0.50 m-dotsol = 1503 lb/hr

1.17 q sol 

### = m -dot vol 

### /ρ sol 

### qsol = 1503 * 7.481 / 71 qsol = 158 gph

2.35 Tank Volume = q sol 

### t Tank Volume = 158 * 14 * 24 Tank Volume = 53,198 gal

### Direct Capital Cost

1.19 DC = ($950/mmBtu/hr) * Q B 

### (mmBtu/hr)[(2375/mmBtu/hr)/Q B 

### (mmBtu/hr] 0.577 

### * (0.66 + 0.85* η NOx 

### ) DC = 950 $ * 5130 *( 2375 / 5130 )^ 0.577 *( 0.66 + 0.85 * 37% ) DC = 3,038,006 $

**Inflation A djustment =**  1.34

DC = 4,070,928 $

### Indirect Capital Costs

**Total Direct Capital Costs, A** 4,070,928 $ Indirect Installation Costs

General Facilities 0.05 A $203,546 Engineering and Hom e Office Fees 0.10 A $407,093 Process Contingencies 0.05 A $203,546 **Total Indirect Installation Costs, B** 0.20 A $814,186

Project Contingency , C = 0.15 (A+B) $732,767 **Total Plant Cost D =** A+B+C $5,617,880

Preproduction Cost 0.02 D $112,358 Inventory Capital $119,911 **Total Capital Investment TCI = D+G+H** +D+E+F+G+H+I $5,850,149

Company

TCI = 7,800,000 $**Annual Costs**

2.45 DAC = Annual Maintenance Cost + Annual Reagent Cost + Annual Electricity Cost + Annual W ater Cost + Annual Catalyst Cost 2.46 Annual Maintenance Cost = 0.015 TCI Annual Maintenance Cost = 0.015 * 7,800,000 $ Annual Maintenance Cost = 117,000 $ 1.22 Annual Reagent Cost = q sol Cost reagent t op 1.22.a t op = CF total 8760hr/yr top = 86.5% * 8760 top = 7577 Annual Reagent Cost = 158 * 2.254 * 7577 Annual Reagent Cost = 2,704,208 $ 1.24 Annual Electricity Cost = Power (Cost elect )t op 1.23 Power = 0.47NOx in NSRQ B /9.5 Power = 0.47 * 0.482 * 1.27 * 5130 / 9.5 Power = 155 kW Annual Electricity Cost = 155 * 7577 * 0.038 Annual Electricity Cost = 44,656 $ 1.27 Annual W ater Cost = q water Cost water t op 1.25 q water

= m-dot sol /ρ water [Curea stored /Curea sol inj -1] qwater = 1503 / 8.345 *( 50% / 10%

- 1 ) qwater = 720 Annual W ater Cost = 720 * 0.0004 * 7577 Annual W ater Cost = 2,183 $ 1.31 Annual ΔCoal cost = ΔCoal cost coal t op 1.28 ΔCoal(Btu/hr) = Hv(Btu/lb)* m-dot reagent (lb/hr)[1/ Curea sol inj -1] ΔCoal(Btu/hr) = 900 * 1503 *( 1 / 10%

- 1 ) ΔCoal(Btu/hr) = 12,171,420 Annual ΔCoal cost = 12.2 * 0.91 $ * 7577 Annual ΔCoal cost = 83,927

$

1.32 Annual ΔAsh cost = ΔAsh cost ash t op 1.30 ΔAsh = ΔCoal ash product/HHV ΔAsh = 12 * 77000 / 6548 ΔAsh = 143 Annual ΔAsh cost = 143 * 11.28 $ * 7577 / 2000 Annual ΔAsh cost = 6,117

$

Total Variable Cost = 2,841,090

$

Total Direct Annual Cost = 117,000 $ + 2,841,090 $ Total Direct Annual Cost = 2,958,090 $

1.34 CRF = i(1+i) n /[(1+i) n -1] CRF = 0.07 *( 1 + 0.07 )^ 20 /(( 1 + 0.07 )^ 20

- 1 ) CRF = 0.0944 1.33 IDAC = CRF*TCI Indirect Annual Cost = 0.0944 * 7,800,000 $ Indirect Annual Cost = 736,265 $

1.35 Total Annual Cost = Direct Annual Cost + Indirect Annual Cost Total Annual Cost = 2,958,090

$ + 736,265 Total Annual Cost = 3,694,355

$

1.36 NOx Removed = NOx in η NOx Q B t op NOx Removed = 0.482 * 37% * 5130 * **7577** / 2000 NOx Removed = 3440

1.37 Cost effectiveness = TAC/NO x removed Cost effectiveness = 1,074

$**Leland Olds Station Unit 2, EPA's SNCR Cost Analy sis Summary** 

**Operating company Basin Electric power**  **Facility Leland Olds**  **State ND**  **Contact Tom Bachman**  **tbachman@nd.gov (701) 328-5188** 

**Proposed Controls proposed ASOFA + SNCR**  Unit #2 Boiler Ty pe cyclone ND DOH report (SIP Appendix B.1) Fuel ND lignite & PRB ND DOH report (SIP Appendix B.1) Rating (MW Gross) each 440 ND DOH report (SIP Appendix B.1) **Presumptive BART limit (lb/mmBtu) 0.10**  **presumptive BART for cy clone boiler at facility**  **> 750 MW** Rating (mmBtu/hr) 5,130 ND DOH report (SIP Appendix B.1) (and the Fox report) Uncontrolled Emissions (tpy) 13,022 calculated Uncontrolled Emissions (lb/mmBtu) 0.67 ND DOH report (SIP Appendix B.1) (and the Fox report)

**ASOFA Cost Analysis** Control Efficiency 28% ND DOH report (SIP Appendix B.1) Controlled emissions (lb/mmBtu) 0.482 ND DOH report (SIP Appendix B.1) Controlled Emissions (tpy) 9,329 calculated from Fox report Emissions Reduction (tpy) 3,693 calculated from Fox report Capital Cost 11,440,000 $ calculated from Table 2.5-2 in the 5/27/09 company report (and the Fox report "ASOFA+SCR" tab) Capital Cost ($/kW ) 26 $ company report (and the Fox report "ASOFA+SCR" tab) O&M Cost 177,000 $ from Table 2.5-3 in the 5/27/09 company report Annualized Cost 1,256,855 $ calculated from Tables 2.5-2 & 2.5-3 in the 5/27/09 company report Cost-Effectiveness ($/ton) 340 $ calculated

**SNCR Cost Analy sis**  Control Efficiency 37% calculated Controlled emissions (lb/mmBtu) 0.305 ND DOH report (SIP Appendix B.1) Controlled Emissions (tpy) 5,889 calculated Emissions Reduction (tpy) 3,440 OAQPS Control Cost Manual Capital Cost 7,800,000 $ calculated from Table 2.5-2 in the 5/27/09 company report Capital Cost ($/kW ) 18 $ calculated O&M Cost 2,958,090 $ hybrid Annualized Cost 3,694,355 $ hybrid Cost-Effectiveness ($/ton) 1,074 $ hybrid

**ASOFA+SNCR Cost Analy sis**  Control Efficiency 54% calculated Controlled emissions (lb/mmBtu) 0.305 calculated Controlled Emissions (tpy) 5,889 calculated Emissions Reduction (tpy) 7,133 calculated Capital Cost 19,240,000 $ calculated Capital Cost ($/kW ) 44 $ calculated O&M Cost 3,135,090 $ calculated Annualized Cost 4,951,210 $ calculated Cost-Effectiveness ($/ton) 694 $ calculated